This recommended practice is based on global industry best practices and serves as a guide for those who are concerned with the design and construction of new fixed offshore platforms and for the relocation of existing platforms used for the drilling, development, production, and storage of hydrocarbons in offshore areas.

This standard is available for purchase at the API Publication Store:https://www.apiwebstore.org/standards/2A-WSD 

This document provides requirements and guidance for the structural design and/or assessment of floating offshore platforms used by the petroleum and natural gas industries to support the following functions:

⎯ production;

⎯ storage and/or offloading;

⎯ drilling and production;

⎯ production, storage and offloading;

⎯ drilling, production, storage and offloading.

NOTE 1 Floating offshore platforms are often referred to using a variety of abbreviations, e.g. FPS, FSU, FPSO, etc. (see Clauses 3 and 4), in accordance with their intended mission.

NOTE 2 In this standard, the term “floating structure”, sometimes shortened to “structure”, is used as a generic term to indicate the structural systems of any member of the classes of platforms defined above.

NOTE 3 In some cases, floating platforms are designated as “early production platforms”. This term relates merely to an asset development strategy. For the purposes of this International Standard, the term “production” includes “early production”.

Its requirements do not apply to the structural systems of mobile offshore units (MOUs). These include, among others:

⎯ floating structures intended primarily to perform drilling and/or well intervention operations (often referred to as MODUs), even when used for extended well test operations;

⎯ floating structures used for offshore construction operations (e.g. crane barges or pipelay barges), for temporary or permanent offshore living quarters (floatels), or for transport of equipment or products (e.g. transportation barges, cargo barges), for which structures reference is made to relevant recognized classification society (RCS) rules.

Its requirements are applicable to all possible life-cycle stages of the structures defined above, such as

⎯ design, construction and installation of new structures, including requirements for inspection, integrity management and future removal,

⎯ structural integrity management covering inspection and assessment of structures in-service, and

⎯ conversion of structures for different use (e.g. a tanker converted to a production platform) or reuse at different locations.

The following types of floating structure are explicitly considered within the context of this standard:

a) monohulls (ship-shaped structures and barges);

b) semi-submersibles;

c) spars.

In addition to the structural types listed above, this standard covers other floating platforms intended to perform the above functions, consisting of partially submerged buoyant hulls made up of any combination of plated and space frame components and used in conjunction with the stationkeeping systems covered in API 2SK. These other structures can have a great range of variability in geometry and structural forms and, therefore, can be only partly covered by the requirements of this standard. In other cases, specific requirements stated in this standard can be found not to apply to all or part of a structure under design.

In all the above cases, conformity with this standard will require that the design is based upon its underpinning principles and achieves a level of safety equivalent, or superior, to the level implicit in it.

NOTE The speed of evolution of offshore technology often far exceeds the pace at which the industry achieves substantial agreement on innovation in structural concepts, structural shapes or forms, structural components and associated analysis and design practices, which are continuously refined and enhanced. On the other hand, International Standards can only capture explicit industry consensus, which requires maturation and acceptance of new ideas. Consequently, advanced structural concepts can, in some cases, only be partly covered by the provisions of standard.

This standard is applicable to steel floating structures. The principles documented herein are, however, considered to be generally applicable to structures fabricated in materials other than steel.

Similarly, while this document is directly applicable to oil and gas producing platforms operating at ambient temperature, the principles documented herein are considered to be generally applicable to structures used in conjunction with cryogenic processes, such as floating liquefied gas (FLNG) plants, with the exception of the aspects related to handling and storage of cryogenic liquids.

The structural design and fabrication of the drilling and production modules supported by a floating structure can be carried out in accordance with API 2A–WSD, 21^st Edition, Errata and Supplement 3.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

API 17A provides general requirements and recommendations for the development of subsea production systems, from the design phase to decommissioning and abandonment. This document also references to other API 17-series documents as well as various other relevant industry documents.

The complete subsea production system comprises several subsystems necessary to produce hydrocarbons from one or more subsea wells and transfer them to a given processing facility located offshore (fixed, floating, or subsea) or onshore, or to inject water/gas through subsea wells.

This document, given its broad scope, has a systems engineering section. The purpose of this section is to help ensure consistency across the various subsystems.

If requirements as stated in this document are in conflict with, or are inconsistent with, requirements as stated in other API 17-series documents, then the specific requirements in the subsystems series document(s) take precedence.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This recommended practice (RP) aims to provide operators, contractors and suppliers with guidance on the management and application of reliability and integrity management (RIM) engineering techniques in subsea projects and operations within their scope of work and supply. It is applicable to:

— standard and nonstandard equipment (within the scope of API 17A);

— new field developments, further development of existing fields and field upgrades;

— all life cycle phases from feasibility through design, manufacture, and operation to decommissioning.

NOTE API 18LCM ^[1] gives additional guidance on general requirements for life cycle management of equipment.

This RP is not intended to replace individual company processes, procedures, document nomenclature, or numbering; it is a guide. For example, this RP does not prescribe the use of any specific equipment or process. It does not recommend any actions, beyond good engineering practice. However, this RP may be used to enhance existing processes, if deemed appropriate.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This standard describes the minimum specifications for electronic gas measurement systems used in the measurement and recording of flow parameters of gaseous phase hydrocarbon and other related fluids for custody transfer applications utilizing industry recognized primary measurement devices.

Electronic gas measurement (EGM) systems may be comprised of a number of components which work together to measure and record gas flow as shown in Figure 1. The components contained in the cloud are considered part of the EGM system. The components may be considered individually or be integral parts of the EGM system and the calculations may be performed onsite and/or off-site.

This standard provides the minimum reporting and change management requirements of the various intelligent components required for accurate and auditable measurement. The requirements can be met by a combination of electronically and/or manually recorded configuration, test reports, change record reporting of the electronic gas measurement system components and flow parameters. It is recognized that diagnostic capabilities of the newer meter and transmitter technologies are important but due to the device specific complexity, intelligent device diagnostics are out of scope for this standard.

For all existing installations, the decision to upgrade the system to satisfy the current standard is at the discretion of the parties involved

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

General

This document defines the application criteria for UFMs and addresses the appropriate considerations regarding the liquids to be measured. This document addresses the installation, operation, and maintenance of UFMs in liquid hydrocarbon service.

Field of Application

The field of application of this standard is the dynamic measurement of liquid hydrocarbons. While this document is specifically written for custody transfer measurement, other acceptable applications may include allocation measurement, check meter measurement, and leak detection measurement. This document only pertains to spool type, multi-path ultrasonic flow meters with permanently affixed acoustic transducer assemblies.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This test method covers the determination, using a glass thermohydrometer in conjunction with a series of calculations, of the density, relative density, or API gravity of crude petroleum, petroleum products, or mixtures of petroleum and nonpetroleum products normally handled as liquids and having a Reid vapor pressures of 101.325 kPa (14.696 psi) or less. Values are determined at existing temperatures and corrected to 15 °C or 60 °F by means of a series of calculations and international standard tables. 

The initial thermohydrometer readings obtained are uncorrected hydrometer readings and not density measurements. Readings are measured on a thermohydrometer at either the reference temperature or at another convenient temperature, and readings are corrected for the meniscus effect, the thermal glass expansion effect, alternate calibration temperature effects and to the reference temperature by means of calculations and Adjunct to D1250 Guide for Use of the Petroleum Measurement Tables (API MPMS Chapter 11.1). 

Readings determined as density, relative density, or API gravity can be converted to equivalent values in the other units or alternate reference temperatures by means of Interconversion Procedures (API MPMS Chapter 11.5) or Adjunct to D1250 Guide for Use of the Petroleum Measurement Tables (API MPMS Chapter 11.1), or both, or tables as applicable. 

The initial thermohydrometer reading shall be recorded before performing any calculations. The calculations required in Section 9 shall be applied to the initial thermohydrometer reading with observations and results reported as required by Section 11 prior to use in a subsequent calculation procedure (measurement ticket calculation, meter factor calculation, or base prover volume determination). 

Annex A1 contains a procedure for verifying or certifying the equipment of this test method. 

The values stated in SI units are to be regarded as standard. 

Exception—The values given in parentheses are for information only. 

This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use. 1.8 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

This standard is available for purchase at the API Publication Store:  https://www.apiwebstore.org/standards/9_3

This standard establishes the basic concepts and procedures to estimate and report meter performance uncertainty in consistent and comparable ways.

This standard is available for purchase at the API Publication Store: https://www.apiwebstore.org/standards/13_2

This standard reviews basic statistical concepts and uses such to establish a methodology to develop uncertainty analyses for use in writing API Manual of Petroleum Measurement Standards (MPMS) documents that are consistent with the ISO GUM and NIST Technical Note 1297.

This standard is available for purchase at the API Publication Store: https://www.apiwebstore.org/standards/13_3  
 

The purpose of this standard is to provide a comprehensive guideline for properly collecting, conditioning, and handling representative samples of natural gas that are at or above their hydrocarbon dew point.

The standard considers spot, composite, continuous, and mobile sampling systems. This standard does not include sampling of liquid streams.

This standard includes comments identifying special areas of concern or importance for each sampling method included. It is intended for custody transfer measurement systems and may be applicable to allocation measurement systems.

The accuracy of moisture determinations from samples collected using the recommendations in this standard has not been determined.

This standard is available for purchase at the API Publication Store: https://www.apiwebstore.org/standards/14_1